US20220381097A1 - Downhole torque limiter - Google Patents
Downhole torque limiter Download PDFInfo
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- US20220381097A1 US20220381097A1 US17/335,492 US202117335492A US2022381097A1 US 20220381097 A1 US20220381097 A1 US 20220381097A1 US 202117335492 A US202117335492 A US 202117335492A US 2022381097 A1 US2022381097 A1 US 2022381097A1
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- clutch mechanisms
- pipe
- tubular housing
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- 239000012530 fluid Substances 0.000 claims abstract description 88
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- 238000000429 assembly Methods 0.000 description 25
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- 230000003993 interaction Effects 0.000 description 4
- 239000004215 Carbon black (E152) Substances 0.000 description 3
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
- 230000002706 hydrostatic effect Effects 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 238000007792 addition Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 238000012217 deletion Methods 0.000 description 1
- 230000037430 deletion Effects 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 239000013505 freshwater Substances 0.000 description 1
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Images
Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/02—Couplings; joints
- E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/02—Couplings; joints
- E21B17/04—Couplings; joints between rod or the like and bit or between rod and rod or the like
- E21B17/06—Releasing-joints, e.g. safety joints
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16D—COUPLINGS FOR TRANSMITTING ROTATION; CLUTCHES; BRAKES
- F16D7/00—Slip couplings, e.g. slipping on overload, for absorbing shock
- F16D7/04—Slip couplings, e.g. slipping on overload, for absorbing shock of the ratchet type
- F16D7/06—Slip couplings, e.g. slipping on overload, for absorbing shock of the ratchet type with intermediate balls or rollers
- F16D7/10—Slip couplings, e.g. slipping on overload, for absorbing shock of the ratchet type with intermediate balls or rollers moving radially between engagement and disengagement
Definitions
- a reduced diameter drillpipe and their threaded connections have lower torque specifications than a larger diameter drillpipe it may be connected to. It may therefore be desirable to limit the magnitude of the torque transferred to the reduced diameter section of drillpipe to prevent damage to the smaller pipe.
- torque is used to refer to the turning force applied to an object measured in force-distance units.
- FIG. 1 illustrates a schematic partial cross-sectional view of an example well system for hydrocarbon reservoir production according to one or more embodiments disclosed herein;
- FIG. 2 illustrates one embodiment of a downhole torque limiter designed and manufactured according to one or more embodiments of the disclosure
- FIG. 3 is a section view of a downhole torque limiter designed and manufactured according to one or more embodiments of the disclosure
- FIG. 4 A is a section view of a center portion of the torque limiter shown in FIG. 3 , shown in an engaged state;
- FIG. 4 B is a section view of the center portion of the torque limiter shown in FIG. 3 , shown in a disengaged state;
- FIG. 4 C is an external view of the center portion of the torque limiter shown in FIG. 3 ;
- FIG. 5 is a section view of an upper driver end of the torque limiter shown in FIG. 3 ;
- FIG. 6 is a section view of a lower driven end of the torque limiter shown in FIG. 3 .
- connection Unless otherwise specified, use of the terms “connect,” “engage,” “couple,” “attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to a direct interaction between the elements and may also include an indirect interaction between the elements described.
- use of the terms “up,” “upper,” “upward,” “uphole,” “upstream,” or other like terms shall be construed as generally away from the bottom, terminal end of a well; likewise, use of the terms “down,” “lower,” “downward,” “downhole,” or other like terms shall be construed as generally toward the bottom, terminal end of the well, regardless of the wellbore orientation.
- any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis. In some instances, a part near the end of the well can be horizontal or even slightly directed upwards. Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.
- the well system 100 in one or more embodiments, generally includes a substantially cylindrical wellbore 110 extending from a wellhead 120 at the surface 130 downward into the Earth and into one or more subterranean zones of interest (one subterranean zone of interest 140 shown).
- the subterranean zone 140 can correspond to a single formation, a portion of a formation, or more than one formation accessed by the well system 100 , and a given well system 100 can access one, or more than one, subterranean zone 140 .
- a portion of the wellbore 110 extending from the wellhead 120 to the subterranean zone 140 may be lined with lengths of tubing, called casing 150 .
- the depicted well system 100 is a vertical well, with the wellbore 110 extending substantially vertically from the surface 130 to the subterranean zone 140 .
- the concepts herein, however, are applicable to many other different configurations of wells, including horizontal, slanted or otherwise deviated wells, and multilateral wells with legs deviating from an entry well.
- a tubing string 160 is shown as having been lowered from the surface 130 into the wellbore 110 .
- the tubing string 160 may be a drillstring having a series of jointed lengths of tubing coupled together end-to-end and/or a continuous (e.g., not jointed) coiled tubing.
- the tubing string 160 may include one or more well tools, including a bottom hole assembly 170 .
- the bottom hole assembly 170 can include, for example, a drill bit, a sand screen, a subsurface safety valve, a downhole sensor, an inflow control valve, a multilateral junction, a deflection wedge, or another type of production component.
- the wellbore 110 is being drilled.
- the wellbore 110 can be drilled in stages, and the casing 150 may be installed between stages.
- the tubing string 160 is a completion string, a service string, coiled tubing, or another oilfield tubular.
- the tubing string 160 is used to place a direction wedge for use in the construction of a multilateral junction.
- the downhole torque limiter 180 may include a tubular housing and a pipe (e.g., mandrel, tubular, drill string, pup joint or any other oilfield tubular) positioned within the tubular housing.
- One or more clutch mechanisms may be positioned between the pipe and the tubular housing.
- the one or more clutch mechanisms may be configured to move between an engaged state (e.g., a radially engaged state in one embodiment) to fix the tubular housing relative to the pipe and a disengaged state (e.g., radially disengaged state in one embodiment) to allow with the tubular housing to rotate relative to the pipe.
- a fluid control system may be coupled with an exterior (e.g., radial exterior in one embodiment) side of the one or more clutch mechanisms, the fluid control system configured to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state based upon sensing movement of the pipe relative to the tubular housing.
- the downhole torque limiter 180 may be set at a specified torque magnitude and then connected between a driver and a driven member, such as the tubing string 160 and the downhole assembly 170 .
- the tubing string 160 may be placed in the wellbore 110 and rotated with the rotational force transmitted by the downhole torque limiter 180 until the specified torque is exceeded.
- a pre-determined torque magnitude is reached, the tubing housing and pipe of the downhole torque limiter 180 will begin to rotate relative to one another, which will signal to the fluid control system to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state. Accordingly, the one or more clutch mechanisms will disengage and slip to allow relative rotation between the tubing string 160 and the downhole assembly 170 .
- the one or more clutch mechanisms may remain in the disengaged state until the rotation is stopped or at least the rotation rate is reduced. Once the rotation decreases, the downhole torque limiter 180 may reset without removing the tubing string 160 from the wellbore 110 . When rotation recommences, the downhole torque limiter 180 may transmit rotational force up to the specified torque magnitude.
- FIG. 2 illustrated is a downhole torque limiter 200 in its typical orientation connected in a tubing string located in the wellbore W.
- Tubing string section designated “U” is the upper section and the section designated “L” is the lower section.
- the term “tubing string” or “drill string” or “drill pipe” are used herein to refer to coil tubing, tubing, drill pipe or other tool deployment strings. While the example selected for explanation is tubing string, the torque limiter of the present invention can be used with tubing, casing, downhole tools, or any type of tubular members.
- the downhole torque limiter 200 has an upper driver end 210 and a lower driven end 220 .
- upper driver end 210 and lower driven end 220 have threaded connections for making up the downhole torque limiter 200 within a tubing string, for example, a drill string.
- a central bore B (not shown in FIG. 2 ) extends the length of the downhole torque limiter 200 , to permit fluids to be pumped through the tool and down the tubing string.
- Upper driver end 210 in one or more embodiments, is connected to upper section U by a threaded connection.
- the upper section U is connected to the surface rig and can be raised, lowered, and rotated thereby.
- Lower driven end 220 is connected to the reduced diameter lower section L.
- a smaller diameter wellbore casing can be present, necessitating the use of the reduced diameter lower section L to access the smaller diameter wellbore casing.
- the downhole torque limiter 200 connects upper U and lower L sections together and transmits rotational movement and torque to lower section L.
- the downhole torque limiter 200 can be set up to allow the upper driver end 210 and the lower driven end 220 to slip with respect to each other when the magnitude of the torque applied to downhole torque limiter 200 exceeds the preset limit.
- the downhole torque limiter 200 will allow the upper driver end 210 and the lower driven end 220 to slip.
- the downhole torque limiter 200 when rotation of the upper driver end 210 ceases or is reduced, the downhole torque limiter 200 will reset to condition where the ends no longer slip with respect to each other, and rotational movement and torque will be transferred to lower section L.
- the downhole torque limiter 300 includes a tubular housing 305 having an upper driver end 310 , shown in more detail in FIG. 5 ; and a lower driven end 320 , shown in more detail in FIG. 6 , and a center portion 330 , shown in more detail in FIGS. 4 A through 4 C .
- the downhole torque limiter 300 may include a pipe 410 positioned within the tubular housing 305 .
- One or more clutch mechanisms which in some embodiments may be piston assemblies 420 , may be positioned between the pipe 410 and the tubular housing 305 .
- the piston assemblies 420 may be configured to move between an engaged state, as shown in FIG. 4 A , and a disengaged state, as shown in FIG. 4 B .
- the tubular housing 305 may be fixed relative to the pipe 410 .
- the piston assemblies 420 are in a disengaged state
- the tubular housing 305 may rotate relative to the pipe 410 .
- the downhole torque limiter 300 may include a fluid control system 430 fluidly coupled with an exterior E (e.g., radial exterior in one embodiment) of the piston assemblies 420 , which may include one or more fluid chambers 435 .
- the fluid control system 430 may be configured to allow the piston assemblies 420 to move from the engaged state to the disengaged state based upon sensing movement of the pipe 410 relative to the tubular housing 305 .
- the fluid control system 430 may include electronics 480 configured to sense movement of the pipe 410 relative to the tubular housing 305 and send a signal to the fluid control system 430 to regulate the fluid pressure in the exterior E, and thus allow or disallow relative movement.
- the piston assemblies 420 may be hydraulic pistons and fluid pressure in the exterior E may maintain the piston assemblies 420 in an engaged state with the pipe 410 .
- the piston assemblies 420 may further include a spring 425 , which itself may resist a certain amount of torque between the tubular housing 305 and the pipe 410 , such that the piston assemblies 420 remain engaged with the pipe 410 .
- the fluid control system 430 may include a hydraulic pump 440 in fluid connection with the exterior E, wherein the hydraulic pump 440 may be configured to control fluid pressure in the exterior E.
- the hydraulic pump 440 may further include a motor 445 and associated gearbox 450 .
- the hydraulic pump 440 may control fluid pressure in the exterior E. As a pre-set torque value is reached, the hydraulic pump 440 may reduce fluid pressure in the exterior E such that the piston assemblies 420 may move at least partially from the fully engaged state shown in FIG. 4 A .
- the pre-set torque value is between 100 ft-lbs. and 100,000 ft-lbs. In yet another embodiment, the pre-set torque value is between 500 ft-lbs. and 5000 ft-lbs. When the piston assemblies 420 are in a fully engaged state, the piston assemblies 420 may fully engage the pipe 410 .
- the piston assemblies 420 may remain partially engaged such that the piston assemblies 420 may still engage protrusions 415 positioned about the pipe 410 and as such, the tubular housing 305 may, in some embodiments, be able to partially rotate with the pipe 410 .
- the torque limit can be adjusted, in one or more embodiments, by adjusting the amount of fluid that is pumped by the hydraulic pump 440 .
- the hydraulic pump 440 may suction the fluid from the exterior E such that the piston assemblies 420 are moved to a substantially disengaged state from the pipe 410 .
- the piston assemblies 420 may rotate freely with respect to the protrusions 415 and the pipe 410 , and thus there is no contact between the piston assemblies 420 and the protrusions 415 .
- the downhole torque limiter 300 may include a pressure relief valve 460 .
- the pressure relief valve 460 may be configured to allow fluid from the exterior E of the piston assemblies 420 to move to an interior I (e.g., radial interior in one embodiment) of the of the piston assemblies 420 upon failure of the fluid control system 430 and sensing a high-pressure situation.
- a high-pressure situation is a pressure situation that is at least 100 psi greater than the hydrostatic downhole pressure.
- a high-pressure situation is a pressure situation that is at least 1,000 psi greater than the hydrostatic downhole pressure.
- the high-pressure situation is a pressure situation ranging from about 100 psi to about 10,000 psi greater than the hydrostatic downhole pressure.
- the fluid may, in some embodiments, move within the fluid chambers 435 in an uphole direction from the piston assemblies 420 and through the pressure relief valve 460 .
- the downhole torque limiter 300 may further include a one-way check valve 470 configured to allow fluid to move from the disengaged interior I of the piston assemblies 420 to the exterior E of the piston assemblies 420 when the high-pressure situation has been relieved. Thus, the piston assemblies 420 may then move back at least partially into the engaged state with the pipe 410 .
- the electronics 480 may send a signal to the hydraulic pump 440 , whereafter the hydraulic pump 440 may adjust the fluid pressure in the exterior E according to the amount of movement.
- the electronics 480 may include a sensor 485 which is configured to sense the movement and/or vibration of the pipe 410 .
- the sensor 485 in at least one embodiment, is an acoustic sensor or a magnetic sensor.
- the acoustic sensor could be a piezoelectric sensor, an accelerometer, a microphone, a ferroelectric sensor, a strain gauge, a pressure sensor, among others.
- the electronics 480 may also include a controller and a power supply, which in some embodiments may be a circuit board assembly 490 and one or more batteries 495 .
- the circuit board assembly 490 may connect with the hydraulic pump 440 , motor 445 , and the gearbox 450 .
- the upper driver end 310 of the housing 305 may, be fixed with respect to the pipe 410 .
- the upper driver end 310 may include various components which may work in conjunction with the hydraulic pump system 430 and support rotation of the housing 305 .
- the upper driver end may include a balance piston 520 , pre-load springs 530 , and bearings 540 , which may include both radial and thrust bearings.
- the upper driver end 310 may also include a rotary seal 550 , which may provide a seal about an upper end of the pipe 410 .
- the lower driven end 320 may engage and disengage with the pipe 410 for rotation therewith.
- the lower driven end 320 may include additional features which may work in conjunction with the hydraulic pump system 430 and support rotation of the lower driven end 320 .
- the lower driven end 320 may include a radial bearing 630 positioned about the pipe 410 and a balance piston 640 .
- a downhole torque limiter may utilize other components in conjunction with or in place of certain components disclosed herein.
- a downhole torque limiter may utilize a solenoid valve and pump.
- a downhole torque limiter may utilize a generator to supply power to embodiments of the electronics 480 , wherein the generator may be driven by relative rotation of the pipe and housing.
- the downhole torque limiter may use relative rotation within the downhole torque limiter to drive a mechanical pump for controlling fluid exterior to the one or more clutch mechanisms.
- a downhole torque limiter including: 1) a tubular housing; 2) a pipe positioned within the tubular housing; 3) one or more clutch mechanisms positioned between the pipe and the tubular housing, the one or more clutch mechanisms configured to move between a engaged state to fix the tubular housing relative to the pipe and a disengaged state to allow with the tubular housing to rotate relative to the pipe; and 4) a fluid control system coupled with an exterior of the one or more clutch mechanisms, the fluid control system configured to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state based upon sensing movement of the pipe relative to the tubular housing.
- a well system including: 1) a wellbore; 2) a tubing string positioned within the wellbore; 3) a torque limiter coupled with the tubing string, the torque limiter including: a) a tubular housing; b) a pipe positioned within the tubular housing; c) one or more clutch mechanisms positioned between the pipe and the tubular housing, the one or more clutch mechanisms configured to move between a engaged state to fix the tubular housing relative to the pipe and a disengaged state to allow with the tubular housing to rotate relative to the pipe; and d) a fluid control system coupled with an exterior of the one or more clutch mechanisms, the fluid control system configured to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state based upon sensing movement of the pipe relative to the tubular housing.
- a method for limiting torque in a well system including: 1) running a downhole torque limiter into a wellbore, the downhole torque limiter coupled with at least a tubing string and including: a) a tubular housing; b) a pipe positioned within the tubular housing; c) one or more clutch mechanisms positioned between the pipe and the tubular housing, the one or more clutch mechanisms configured to move between a engaged state to fix the tubular housing relative to the pipe and a disengaged state to allow with the tubular housing to rotate relative to the pipe; and d) a fluid control system coupled with a exterior of the one or more clutch mechanisms, the fluid control system configured to allow the one or more clutch mechanisms to move between the engaged state to the disengaged state; e) wherein the fluid control system includes electronics configured to sense movement of the pipe relative to the tubular housing and send a signal to a hydraulic pump of the fluid control system; 2) sensing movement of the pipe relative to the tubular housing using the electronics; 3) sending a signal to the hydraulic pump to
- each of the one or more clutch mechanisms includes a piston assembly.
- Element 2 wherein the piston assembly is held in the engaged state by fluid pressure against the exterior of the piston assembly.
- Element 3 wherein the piston assembly includes a spring, wherein the piston assembly is held in the engaged state by the spring.
- Element 4 wherein the fluid control system includes a hydraulic pump configured to control fluid pressure against the exterior of the one or more clutch mechanisms.
- Element 5 wherein the hydraulic pump reduces the fluid pressure against the exterior of the one or more clutch mechanisms to allow the one or more clutch mechanisms to move at least partially from the engaged state to the disengaged state.
- Element 6 wherein the hydraulic pump suctions the fluid from the exterior of the one or more clutch mechanisms to move the one or more clutch mechanisms to a substantially disengaged state.
- Element 7 further including a pressure relief valve configured to allow fluid from the exterior of the one or more clutch mechanisms to move to an interior of the of the one or more clutch mechanisms upon failure of the fluid control system and sensing a high-pressure situation.
- Element 8 further including a one-way check valve configured to allow fluid to move from the interior of the one or more clutch mechanisms to the exterior of one or more clutch mechanisms when the high-pressure situation has been relieved.
- Element 9 wherein the fluid control system includes electronics configured to sense movement of the pipe relative to the tubular housing and send a signal to a hydraulic pump of the fluid control system to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state.
- Element 10 wherein the electronics includes an acoustic sensor configured to sense the movement of the pipe.
- Element 11 wherein the tubular housing includes an upper driver end and a lower driven end, wherein the upper driver end is fixed with respect to the pipe and the lower driven end engages and disengages with the pipe.
- Element 12 further including: a pressure relief valve configured to allow fluid from the exterior of the one or more clutch mechanisms to move to a disengaged interior of the of the one or more clutch mechanisms upon failure of the fluid control system and sensing a high-pressure situation; and a one-way check valve configured to allow fluid to move from the disengaged interior of the one or more clutch mechanisms to the exterior of one or more clutch mechanisms when the high-pressure situation has been relieved.
- the fluid control system includes electronics configured to sense movement of the pipe relative to the tubular housing and send a signal to a hydraulic pump of the fluid control system to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state.
- Element 14 wherein the wherein the tubing string is a drillstring and wherein the tubular housing includes an upper driver end and a lower driven end, wherein the upper driver end is coupled with the drillstring and fixed with respect to the pipe and the lower driven end engages and disengages with the pipe.
- Element 15 further including a pressure relief valve configured to allow fluid from the exterior of the one or more clutch mechanisms to move to a disengaged interior of the of the one or more clutch mechanisms upon failure of the fluid control system and sensing a high-pressure situation.
- Element 16 further including a one-way check valve configured to allow fluid to move from the disengaged interior of the one or more clutch mechanisms to the exterior of one or more clutch mechanisms when the high-pressure situation has been relieved.
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Abstract
Description
- A common problem encountered in drilling and servicing hydrocarbon wells is found when using an assembly of pipe sections which steps down in diameter to extend into a relatively smaller diameter borehole below the larger main casing section. For example, in a “drillstring,” or sets of tubing called a tubing string, a reduced diameter drillpipe and their threaded connections have lower torque specifications than a larger diameter drillpipe it may be connected to. It may therefore be desirable to limit the magnitude of the torque transferred to the reduced diameter section of drillpipe to prevent damage to the smaller pipe. As used herein, the term “torque” is used to refer to the turning force applied to an object measured in force-distance units.
- Traditional downhole torque limiting systems employ shear pins or other elements, which are designed to fail when a specified torque is exceeded, allowing the pipe sections to rotate with respect to each other. To reset these devices, the tubing string must be removed from the well and the fractured pin replaced, which is undesirable and expensive. Alternatively, a weight may be inserted into the wellbore to reset the pipe sections, which is undesirable for other reasons.
- Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:
-
FIG. 1 illustrates a schematic partial cross-sectional view of an example well system for hydrocarbon reservoir production according to one or more embodiments disclosed herein; -
FIG. 2 illustrates one embodiment of a downhole torque limiter designed and manufactured according to one or more embodiments of the disclosure; -
FIG. 3 is a section view of a downhole torque limiter designed and manufactured according to one or more embodiments of the disclosure; -
FIG. 4A is a section view of a center portion of the torque limiter shown inFIG. 3 , shown in an engaged state; -
FIG. 4B is a section view of the center portion of the torque limiter shown inFIG. 3 , shown in a disengaged state; -
FIG. 4C is an external view of the center portion of the torque limiter shown inFIG. 3 ; -
FIG. 5 is a section view of an upper driver end of the torque limiter shown inFIG. 3 ; and -
FIG. 6 is a section view of a lower driven end of the torque limiter shown inFIG. 3 . - In the drawings and descriptions that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawn figures are not necessarily to scale. Certain features of the disclosure may be shown exaggerated in scale or in somewhat schematic form and some details of certain elements may not be shown in the interest of clarity and conciseness. The present disclosure may be implemented in embodiments of different forms.
- Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.
- Unless otherwise specified, use of the terms “connect,” “engage,” “couple,” “attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to a direct interaction between the elements and may also include an indirect interaction between the elements described. Unless otherwise specified, use of the terms “up,” “upper,” “upward,” “uphole,” “upstream,” or other like terms shall be construed as generally away from the bottom, terminal end of a well; likewise, use of the terms “down,” “lower,” “downward,” “downhole,” or other like terms shall be construed as generally toward the bottom, terminal end of the well, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis. In some instances, a part near the end of the well can be horizontal or even slightly directed upwards. Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.
- Referring now to
FIG. 1 , illustrated is a schematic partial cross-sectional view of anexample well system 100 for hydrocarbon reservoir production, according to certain example embodiments. Thewell system 100, in one or more embodiments, generally includes a substantiallycylindrical wellbore 110 extending from awellhead 120 at thesurface 130 downward into the Earth and into one or more subterranean zones of interest (one subterranean zone ofinterest 140 shown). Thesubterranean zone 140 can correspond to a single formation, a portion of a formation, or more than one formation accessed by thewell system 100, and a givenwell system 100 can access one, or more than one,subterranean zone 140. After some or all of thewellbore 110 is drilled, a portion of thewellbore 110 extending from thewellhead 120 to thesubterranean zone 140 may be lined with lengths of tubing, calledcasing 150. The depictedwell system 100 is a vertical well, with thewellbore 110 extending substantially vertically from thesurface 130 to thesubterranean zone 140. The concepts herein, however, are applicable to many other different configurations of wells, including horizontal, slanted or otherwise deviated wells, and multilateral wells with legs deviating from an entry well. - A
tubing string 160 is shown as having been lowered from thesurface 130 into thewellbore 110. In some instances, thetubing string 160 may be a drillstring having a series of jointed lengths of tubing coupled together end-to-end and/or a continuous (e.g., not jointed) coiled tubing. Thetubing string 160 may include one or more well tools, including abottom hole assembly 170. Thebottom hole assembly 170 can include, for example, a drill bit, a sand screen, a subsurface safety valve, a downhole sensor, an inflow control valve, a multilateral junction, a deflection wedge, or another type of production component. In the example shown, thewellbore 110 is being drilled. Thewellbore 110 can be drilled in stages, and thecasing 150 may be installed between stages. In some instances, thetubing string 160 is a completion string, a service string, coiled tubing, or another oilfield tubular. In one instance, thetubing string 160 is used to place a direction wedge for use in the construction of a multilateral junction. - In certain embodiments, there is a desire and/or need for a downhole torque limiter 180 associated with the
tubing string 160. The downhole torque limiter 180, in some embodiments, may include a tubular housing and a pipe (e.g., mandrel, tubular, drill string, pup joint or any other oilfield tubular) positioned within the tubular housing. One or more clutch mechanisms may be positioned between the pipe and the tubular housing. The one or more clutch mechanisms may be configured to move between an engaged state (e.g., a radially engaged state in one embodiment) to fix the tubular housing relative to the pipe and a disengaged state (e.g., radially disengaged state in one embodiment) to allow with the tubular housing to rotate relative to the pipe. A fluid control system may be coupled with an exterior (e.g., radial exterior in one embodiment) side of the one or more clutch mechanisms, the fluid control system configured to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state based upon sensing movement of the pipe relative to the tubular housing. - In some examples, the downhole torque limiter 180 may be set at a specified torque magnitude and then connected between a driver and a driven member, such as the
tubing string 160 and thedownhole assembly 170. Thetubing string 160 may be placed in thewellbore 110 and rotated with the rotational force transmitted by the downhole torque limiter 180 until the specified torque is exceeded. When a pre-determined torque magnitude is reached, the tubing housing and pipe of the downhole torque limiter 180 will begin to rotate relative to one another, which will signal to the fluid control system to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state. Accordingly, the one or more clutch mechanisms will disengage and slip to allow relative rotation between thetubing string 160 and thedownhole assembly 170. The one or more clutch mechanisms may remain in the disengaged state until the rotation is stopped or at least the rotation rate is reduced. Once the rotation decreases, the downhole torque limiter 180 may reset without removing thetubing string 160 from thewellbore 110. When rotation recommences, the downhole torque limiter 180 may transmit rotational force up to the specified torque magnitude. - Turning to
FIG. 2 , illustrated is adownhole torque limiter 200 in its typical orientation connected in a tubing string located in the wellbore W. Tubing string section designated “U” is the upper section and the section designated “L” is the lower section. The term “tubing string” or “drill string” or “drill pipe” are used herein to refer to coil tubing, tubing, drill pipe or other tool deployment strings. While the example selected for explanation is tubing string, the torque limiter of the present invention can be used with tubing, casing, downhole tools, or any type of tubular members. - The
downhole torque limiter 200 has anupper driver end 210 and a lower drivenend 220. Typically, upper driver end 210 and lower drivenend 220 have threaded connections for making up the downhole torque limiter 200 within a tubing string, for example, a drill string. A central bore B (not shown inFIG. 2 ) extends the length of thedownhole torque limiter 200, to permit fluids to be pumped through the tool and down the tubing string. -
Upper driver end 210, in one or more embodiments, is connected to upper section U by a threaded connection. In the illustrated example, the upper section U is connected to the surface rig and can be raised, lowered, and rotated thereby. Lower drivenend 220 is connected to the reduced diameter lower section L. As is typical, a smaller diameter wellbore casing can be present, necessitating the use of the reduced diameter lower section L to access the smaller diameter wellbore casing. In the illustrated embodiment, thedownhole torque limiter 200 connects upper U and lower L sections together and transmits rotational movement and torque to lower section L. - As will be explained in detail, the
downhole torque limiter 200 can be set up to allow theupper driver end 210 and the lowerdriven end 220 to slip with respect to each other when the magnitude of the torque applied todownhole torque limiter 200 exceeds the preset limit. Thus, when the torque applied by an uphole rig while rotating upper section U exceeds a specified limit, thedownhole torque limiter 200 will allow theupper driver end 210 and the lowerdriven end 220 to slip. According to a particular feature of the present invention, when rotation of theupper driver end 210 ceases or is reduced, thedownhole torque limiter 200 will reset to condition where the ends no longer slip with respect to each other, and rotational movement and torque will be transferred to lower section L. - Referring now to
FIG. 3 , there is shown a section view of adownhole torque limiter 300 designed and manufactured according to one or more embodiments of the disclosure. Thedownhole torque limiter 300 includes atubular housing 305 having anupper driver end 310, shown in more detail inFIG. 5 ; and a lowerdriven end 320, shown in more detail inFIG. 6 , and acenter portion 330, shown in more detail inFIGS. 4A through 4C . - Referring now to
FIG. 4A , there is shown thecenter portion 330 of one embodiment of thedownhole torque limiter 300. Thedownhole torque limiter 300, in this embodiment, may include apipe 410 positioned within thetubular housing 305. One or more clutch mechanisms, which in some embodiments may bepiston assemblies 420, may be positioned between thepipe 410 and thetubular housing 305. Thepiston assemblies 420 may be configured to move between an engaged state, as shown inFIG. 4A , and a disengaged state, as shown inFIG. 4B . When thepiston assemblies 420 are in an engaged state, thetubular housing 305 may be fixed relative to thepipe 410. When thepiston assemblies 420 are in a disengaged state, thetubular housing 305 may rotate relative to thepipe 410. - The
downhole torque limiter 300 may include afluid control system 430 fluidly coupled with an exterior E (e.g., radial exterior in one embodiment) of thepiston assemblies 420, which may include one or morefluid chambers 435. Thefluid control system 430 may be configured to allow thepiston assemblies 420 to move from the engaged state to the disengaged state based upon sensing movement of thepipe 410 relative to thetubular housing 305. In the illustrated embodiment, thefluid control system 430 may includeelectronics 480 configured to sense movement of thepipe 410 relative to thetubular housing 305 and send a signal to thefluid control system 430 to regulate the fluid pressure in the exterior E, and thus allow or disallow relative movement. - In some embodiments, the
piston assemblies 420 may be hydraulic pistons and fluid pressure in the exterior E may maintain thepiston assemblies 420 in an engaged state with thepipe 410. In the illustrated embodiment, thepiston assemblies 420 may further include aspring 425, which itself may resist a certain amount of torque between thetubular housing 305 and thepipe 410, such that thepiston assemblies 420 remain engaged with thepipe 410. - The
fluid control system 430 may include ahydraulic pump 440 in fluid connection with the exterior E, wherein thehydraulic pump 440 may be configured to control fluid pressure in the exterior E. In certain embodiments, thehydraulic pump 440 may further include amotor 445 and associatedgearbox 450. - As shown in
FIG. 4A , thehydraulic pump 440 may control fluid pressure in the exterior E. As a pre-set torque value is reached, thehydraulic pump 440 may reduce fluid pressure in the exterior E such that thepiston assemblies 420 may move at least partially from the fully engaged state shown inFIG. 4A . In at least one embodiment, the pre-set torque value is between 100 ft-lbs. and 100,000 ft-lbs. In yet another embodiment, the pre-set torque value is between 500 ft-lbs. and 5000 ft-lbs. When thepiston assemblies 420 are in a fully engaged state, thepiston assemblies 420 may fully engage thepipe 410. However, under certain conditions, thepiston assemblies 420 may remain partially engaged such that thepiston assemblies 420 may still engageprotrusions 415 positioned about thepipe 410 and as such, thetubular housing 305 may, in some embodiments, be able to partially rotate with thepipe 410. The torque limit can be adjusted, in one or more embodiments, by adjusting the amount of fluid that is pumped by thehydraulic pump 440. - Referring to
FIG. 4B , at another operational condition, the lower tool is engaged, and further rotation would exceed the torque limit. In this operational condition, thehydraulic pump 440 may suction the fluid from the exterior E such that thepiston assemblies 420 are moved to a substantially disengaged state from thepipe 410. As described herein, when thepiston assemblies 420 are in the substantially disengaged state, thepiston assemblies 420 may rotate freely with respect to theprotrusions 415 and thepipe 410, and thus there is no contact between thepiston assemblies 420 and theprotrusions 415. - Referring back to
FIG. 4A , in some embodiments, thedownhole torque limiter 300 may include apressure relief valve 460. Thepressure relief valve 460, in some embodiments, may be configured to allow fluid from the exterior E of thepiston assemblies 420 to move to an interior I (e.g., radial interior in one embodiment) of the of thepiston assemblies 420 upon failure of thefluid control system 430 and sensing a high-pressure situation. In at least one embodiment, a high-pressure situation is a pressure situation that is at least 100 psi greater than the hydrostatic downhole pressure. In at least one other embodiment, a high-pressure situation is a pressure situation that is at least 1,000 psi greater than the hydrostatic downhole pressure. In yet another embodiment, the high-pressure situation is a pressure situation ranging from about 100 psi to about 10,000 psi greater than the hydrostatic downhole pressure. The fluid may, in some embodiments, move within thefluid chambers 435 in an uphole direction from thepiston assemblies 420 and through thepressure relief valve 460. In other embodiments, thedownhole torque limiter 300 may further include a one-way check valve 470 configured to allow fluid to move from the disengaged interior I of thepiston assemblies 420 to the exterior E of thepiston assemblies 420 when the high-pressure situation has been relieved. Thus, thepiston assemblies 420 may then move back at least partially into the engaged state with thepipe 410. - Turning now to
FIG. 4C , in some embodiments, upon sensing a certain amount of movement and, in some examples, vibration of the pipe, theelectronics 480 may send a signal to thehydraulic pump 440, whereafter thehydraulic pump 440 may adjust the fluid pressure in the exterior E according to the amount of movement. In some embodiments, theelectronics 480 may include asensor 485 which is configured to sense the movement and/or vibration of thepipe 410. Thesensor 485, in at least one embodiment, is an acoustic sensor or a magnetic sensor. In at least one embodiment, the acoustic sensor could be a piezoelectric sensor, an accelerometer, a microphone, a ferroelectric sensor, a strain gauge, a pressure sensor, among others. Theelectronics 480 may also include a controller and a power supply, which in some embodiments may be acircuit board assembly 490 and one ormore batteries 495. Thecircuit board assembly 490 may connect with thehydraulic pump 440,motor 445, and thegearbox 450. - Turning now to
FIG. 5 , there is shown theupper driver end 310 of thehousing 305. In some embodiments, theupper driver end 310 may, be fixed with respect to thepipe 410. In the illustrated embodiment, theupper driver end 310 may include various components which may work in conjunction with thehydraulic pump system 430 and support rotation of thehousing 305. For example, the upper driver end may include abalance piston 520, pre-load springs 530, andbearings 540, which may include both radial and thrust bearings. Theupper driver end 310 may also include arotary seal 550, which may provide a seal about an upper end of thepipe 410. - Turning now to
FIG. 6 , there is shown the lowerdriven end 320 of thehousing 305. The lowerdriven end 320, in this embodiment may engage and disengage with thepipe 410 for rotation therewith. In some embodiments, the lowerdriven end 320 may include additional features which may work in conjunction with thehydraulic pump system 430 and support rotation of the lowerdriven end 320. The lowerdriven end 320 may include aradial bearing 630 positioned about thepipe 410 and abalance piston 640. - Other embodiments of a downhole torque limiter may utilize other components in conjunction with or in place of certain components disclosed herein. For example, other embodiments of a downhole torque limiter may utilize a solenoid valve and pump. In other embodiments, a downhole torque limiter may utilize a generator to supply power to embodiments of the
electronics 480, wherein the generator may be driven by relative rotation of the pipe and housing. In yet other embodiments, the downhole torque limiter may use relative rotation within the downhole torque limiter to drive a mechanical pump for controlling fluid exterior to the one or more clutch mechanisms. - Aspects disclosed herein include:
- A. A downhole torque limiter, the downhole torque limiter including: 1) a tubular housing; 2) a pipe positioned within the tubular housing; 3) one or more clutch mechanisms positioned between the pipe and the tubular housing, the one or more clutch mechanisms configured to move between a engaged state to fix the tubular housing relative to the pipe and a disengaged state to allow with the tubular housing to rotate relative to the pipe; and 4) a fluid control system coupled with an exterior of the one or more clutch mechanisms, the fluid control system configured to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state based upon sensing movement of the pipe relative to the tubular housing.
- B. A well system, the well system including: 1) a wellbore; 2) a tubing string positioned within the wellbore; 3) a torque limiter coupled with the tubing string, the torque limiter including: a) a tubular housing; b) a pipe positioned within the tubular housing; c) one or more clutch mechanisms positioned between the pipe and the tubular housing, the one or more clutch mechanisms configured to move between a engaged state to fix the tubular housing relative to the pipe and a disengaged state to allow with the tubular housing to rotate relative to the pipe; and d) a fluid control system coupled with an exterior of the one or more clutch mechanisms, the fluid control system configured to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state based upon sensing movement of the pipe relative to the tubular housing.
- C. A method for limiting torque in a well system, the method including: 1) running a downhole torque limiter into a wellbore, the downhole torque limiter coupled with at least a tubing string and including: a) a tubular housing; b) a pipe positioned within the tubular housing; c) one or more clutch mechanisms positioned between the pipe and the tubular housing, the one or more clutch mechanisms configured to move between a engaged state to fix the tubular housing relative to the pipe and a disengaged state to allow with the tubular housing to rotate relative to the pipe; and d) a fluid control system coupled with a exterior of the one or more clutch mechanisms, the fluid control system configured to allow the one or more clutch mechanisms to move between the engaged state to the disengaged state; e) wherein the fluid control system includes electronics configured to sense movement of the pipe relative to the tubular housing and send a signal to a hydraulic pump of the fluid control system; 2) sensing movement of the pipe relative to the tubular housing using the electronics; 3) sending a signal to the hydraulic pump to control fluid against a exterior of the one or more clutch mechanisms; and 4) controlling fluid against the exterior of the one or more clutch mechanisms to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state.
- Aspects A, B, and C may have one or more of the following additional elements in combination: Element 1: wherein each of the one or more clutch mechanisms includes a piston assembly. Element 2: wherein the piston assembly is held in the engaged state by fluid pressure against the exterior of the piston assembly. Element 3: wherein the piston assembly includes a spring, wherein the piston assembly is held in the engaged state by the spring. Element 4: wherein the fluid control system includes a hydraulic pump configured to control fluid pressure against the exterior of the one or more clutch mechanisms. Element 5: wherein the hydraulic pump reduces the fluid pressure against the exterior of the one or more clutch mechanisms to allow the one or more clutch mechanisms to move at least partially from the engaged state to the disengaged state. Element 6: wherein the hydraulic pump suctions the fluid from the exterior of the one or more clutch mechanisms to move the one or more clutch mechanisms to a substantially disengaged state. Element 7: further including a pressure relief valve configured to allow fluid from the exterior of the one or more clutch mechanisms to move to an interior of the of the one or more clutch mechanisms upon failure of the fluid control system and sensing a high-pressure situation. Element 8: further including a one-way check valve configured to allow fluid to move from the interior of the one or more clutch mechanisms to the exterior of one or more clutch mechanisms when the high-pressure situation has been relieved. Element 9: wherein the fluid control system includes electronics configured to sense movement of the pipe relative to the tubular housing and send a signal to a hydraulic pump of the fluid control system to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state. Element 10: wherein the electronics includes an acoustic sensor configured to sense the movement of the pipe. Element 11: wherein the tubular housing includes an upper driver end and a lower driven end, wherein the upper driver end is fixed with respect to the pipe and the lower driven end engages and disengages with the pipe. Element 12: further including: a pressure relief valve configured to allow fluid from the exterior of the one or more clutch mechanisms to move to a disengaged interior of the of the one or more clutch mechanisms upon failure of the fluid control system and sensing a high-pressure situation; and a one-way check valve configured to allow fluid to move from the disengaged interior of the one or more clutch mechanisms to the exterior of one or more clutch mechanisms when the high-pressure situation has been relieved. Element 13: wherein the fluid control system includes electronics configured to sense movement of the pipe relative to the tubular housing and send a signal to a hydraulic pump of the fluid control system to allow the one or more clutch mechanisms to move from the engaged state to the disengaged state. Element 14: wherein the wherein the tubing string is a drillstring and wherein the tubular housing includes an upper driver end and a lower driven end, wherein the upper driver end is coupled with the drillstring and fixed with respect to the pipe and the lower driven end engages and disengages with the pipe. Element 15: further including a pressure relief valve configured to allow fluid from the exterior of the one or more clutch mechanisms to move to a disengaged interior of the of the one or more clutch mechanisms upon failure of the fluid control system and sensing a high-pressure situation. Element 16: further including a one-way check valve configured to allow fluid to move from the disengaged interior of the one or more clutch mechanisms to the exterior of one or more clutch mechanisms when the high-pressure situation has been relieved.
- Those skilled in the art to which this application relates will appreciate that other and further additions, deletions, substitutions, and modifications may be made to the described embodiments.
Claims (23)
Priority Applications (6)
Application Number | Priority Date | Filing Date | Title |
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GB2314733.3A GB2619662A (en) | 2021-06-01 | 2021-06-01 | Downhole torque limiter |
US17/335,492 US11639636B2 (en) | 2021-06-01 | 2021-06-01 | Downhole torque limiter |
PCT/US2021/035170 WO2022255990A1 (en) | 2021-06-01 | 2021-06-01 | Downhole torque limiter |
NO20231068A NO20231068A1 (en) | 2021-06-01 | 2021-06-01 | Downhole torque limiter |
AU2021448383A AU2021448383A1 (en) | 2021-06-01 | 2021-06-01 | Downhole torque limiter |
CA3215807A CA3215807A1 (en) | 2021-06-01 | 2021-06-01 | Downhole torque limiter |
Applications Claiming Priority (1)
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US17/335,492 US11639636B2 (en) | 2021-06-01 | 2021-06-01 | Downhole torque limiter |
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US20220381097A1 true US20220381097A1 (en) | 2022-12-01 |
US11639636B2 US11639636B2 (en) | 2023-05-02 |
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US17/335,492 Active US11639636B2 (en) | 2021-06-01 | 2021-06-01 | Downhole torque limiter |
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US (1) | US11639636B2 (en) |
AU (1) | AU2021448383A1 (en) |
CA (1) | CA3215807A1 (en) |
GB (1) | GB2619662A (en) |
NO (1) | NO20231068A1 (en) |
WO (1) | WO2022255990A1 (en) |
Citations (4)
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US3981186A (en) * | 1974-07-24 | 1976-09-21 | Teleco Inc. | Device for blocking at a given torque a rotating machine driven by a hydraulic turbine |
US6325163B2 (en) * | 1997-03-21 | 2001-12-04 | Baker Hughes Incorporated | Bit torque limiting device |
US20040238219A1 (en) * | 2003-05-30 | 2004-12-02 | Nichols Richard A. | Drilling string torsional energy control assembly and method |
US20130056223A1 (en) * | 2011-09-01 | 2013-03-07 | Mark B. Nichols | Downhole torque limiter and method |
Family Cites Families (8)
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JP2938347B2 (en) * | 1994-08-05 | 1999-08-23 | 日本車輌製造株式会社 | Torque limiter for construction machinery |
US8607863B2 (en) | 2009-10-07 | 2013-12-17 | Halliburton Energy Services, Inc. | System and method for downhole communication |
US8616292B2 (en) | 2010-03-19 | 2013-12-31 | Halliburton Energy Services, Inc. | Resettable downhole torque limiter and related methods of use |
WO2014099783A1 (en) | 2012-12-19 | 2014-06-26 | Schlumberger Canada Limited | Motor control system |
EP2935757B1 (en) * | 2012-12-19 | 2017-07-05 | Halliburton Energy Services, Inc. | Downhole torque limiting assembly for drill string |
GB2552127B (en) | 2015-05-20 | 2021-04-14 | Halliburton Energy Services Inc | Compression activated bypass valve |
US11131151B2 (en) * | 2017-03-02 | 2021-09-28 | Weatherford Technology Holdings, Llc | Tool coupler with sliding coupling members for top drive |
WO2020112080A1 (en) | 2018-11-26 | 2020-06-04 | Halliburton Energy Services, Inc. | System and method for controlling a downhole operation using a clutch tool |
-
2021
- 2021-06-01 NO NO20231068A patent/NO20231068A1/en unknown
- 2021-06-01 US US17/335,492 patent/US11639636B2/en active Active
- 2021-06-01 GB GB2314733.3A patent/GB2619662A/en active Pending
- 2021-06-01 CA CA3215807A patent/CA3215807A1/en active Pending
- 2021-06-01 WO PCT/US2021/035170 patent/WO2022255990A1/en active Application Filing
- 2021-06-01 AU AU2021448383A patent/AU2021448383A1/en active Pending
Patent Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3981186A (en) * | 1974-07-24 | 1976-09-21 | Teleco Inc. | Device for blocking at a given torque a rotating machine driven by a hydraulic turbine |
US6325163B2 (en) * | 1997-03-21 | 2001-12-04 | Baker Hughes Incorporated | Bit torque limiting device |
US20040238219A1 (en) * | 2003-05-30 | 2004-12-02 | Nichols Richard A. | Drilling string torsional energy control assembly and method |
US20130056223A1 (en) * | 2011-09-01 | 2013-03-07 | Mark B. Nichols | Downhole torque limiter and method |
Also Published As
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US11639636B2 (en) | 2023-05-02 |
NO20231068A1 (en) | 2023-10-06 |
GB2619662A (en) | 2023-12-13 |
GB202314733D0 (en) | 2023-11-08 |
WO2022255990A1 (en) | 2022-12-08 |
CA3215807A1 (en) | 2022-12-08 |
AU2021448383A1 (en) | 2023-10-05 |
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